CN106156439B - A kind of heavy crude reservoir dissolved gas drive method for numerical simulation with foam oil phenomenon - Google Patents

A kind of heavy crude reservoir dissolved gas drive method for numerical simulation with foam oil phenomenon Download PDF

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CN106156439B
CN106156439B CN201610573924.XA CN201610573924A CN106156439B CN 106156439 B CN106156439 B CN 106156439B CN 201610573924 A CN201610573924 A CN 201610573924A CN 106156439 B CN106156439 B CN 106156439B
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孙晓飞
张艳玉
王士林
宋兆尧
许凤桐
冯金良
田丰
吴洁
方潇
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China University of Petroleum East China
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Abstract

A kind of heavy crude reservoir dissolved gas drive method for numerical simulation with foam oil phenomenon, for the method for the invention from microcosmic angle, founding mathematical models describe bubble nucleating, growth rhythm.On this basis, derive diffusion velocity equation of the gas from solution gas into bubble, establish three-dimensional two-phase multicomponent dissolved gas drive mathematical modeling, and combination finite difference method and implicit pressure explicit saturation method (IMPES) solve to it, determine saturation degree, dissolved gas oil ratio, oil production and the gas production of reservoir pressure, oil phase and gas phase.Afterwards, tested with the heavy crude reservoir dissolved gas drive with foam oil phenomenon as foundation, the uncertain parameter of model is determined by the method for experimental fit.Finally, development effectiveness parameter affecting laws are disclosed by the model after fitting, understands foam oil phenomenon, predict oil field production capacity, formulated countermeasures of development and improve the recovery factor of heavy oil reservoir with foam oil phenomenon.

Description

A kind of heavy crude reservoir dissolved gas drive method for numerical simulation with foam oil phenomenon
Technical field
The present invention relates to a kind of heavy crude reservoir dissolved gas drive method for numerical simulation with foam oil phenomenon, belongs to viscous crude oil Hide the analogue technique field of exploitation.
Background technology
Viscous crude resource very abundant in world wide, accounts for more than 1/3rd of petroleum resources total amount.Verify and control in China More than 1,900,000,000 tons of reserves processed, are distributed mainly on more than ten of oil field such as the Liaohe River, Xinjiang, triumph.In addition, as China's oil-gas exploration is opened The internationalization of hair, a large amount of external viscous crude resources are urgently developed.Therefore, it is increasing in conventional gas and oil exploration and development difficulty, the energy Contradiction instantly, greatly develops viscous crude raising recovery efficiency technique and meets national economic development strategy.
Compared with the thick oil thermal recovery methods such as steam soak, lift gravity auxiliary oil drainage, heavy crude reservoir dissolved gas drive was developed Journey is one of economy, the important method of Efficient Development viscous crude resource.In Canada, Venezuela, Albania and China During the heavy crude reservoir dissolved gas drive of part, there is the production feature different from wells in conventional heavy oil reservoir, be concentrated mainly on slowly In the gas-oil ratio rate of climb and higher oil recovery.Research shows that the presence of foam oil phenomenon is above-mentioned special viscous crude oil The main reason for hiding high yield.Therefore, foam oil phenomenon, such special viscous crude dissolved gas drive mistake of accurate simulation how effectively to be simulated Journey, oil field production capacity is predicted, formulating reasonable development countermeasure turns into the key for improving such special recovery factor of heavy oil reservoir.
The generation of foam oil phenomenon is due to that solution gas separates out from viscous crude after strata pressure is down to bubble point pressure, bubble Start to be nucleated, and grown as pressure further declines, it is relatively low due to the higher viscous force of special viscous crude and barometric gradient Diffusion velocity, bubble is dispersed in oil phase, rather than coalescence forms free gas.At present, domestic and foreign scholars propose following reason Said process is simulated by with method：1. wells in conventional heavy oil reservoir dissolved gas drive model.The model is with wells in conventional heavy oil reservoir solution gas Based on driving model, by reducing gas phase permeability saturation curve, heightening the characteristics such as porosity to simulate foam oil phenomenon.② " false bubble point " model：False bubble point pressure is set to adjustable parameter, reflection foam oil reservoir reset pressure keep level is high, production gas and oil Than the low and high abnormal industry characteristics of recovery ratio.2. separated flow model：Think the flowing of gas split-phase with gas saturation in straight Line rises, more than producing free gas after the dispensing gas fraction limit.Therefore, it is special by improving gas phase relative permeability and component Property simulates foam oil phenomenon.3. viscosity reduces model, viscosity caused by foam oil phenomenon is simulated by turning down viscosity of thickened oil Reduce phenomenon.
Because the generation and disappearance of foam oil phenomenon are a dynamic processes, therefore, above-mentioned theory and method only pass through list Secondary regulation permeability saturation curve or physical property characteristic can not describe the microprocesses such as bubble nucleating, growth, it is difficult to characterize exactly Influence of the foam oil phenomenon to viscous crude dissolved gas drive development effectiveness, cause simulation error calculated larger, therefore, it is impossible to be used for Heavy crude reservoir dissolved gas drive process of the simulation with foam oil phenomenon.
The content of the invention
For existing theoretical and method deficiency, the present invention provides a kind of heavy crude reservoir solution gas with foam oil phenomenon Drive method for numerical simulation.
Summary of the invention：
For the method for the invention from microcosmic angle, founding mathematical models describe bubble nucleating, growth rhythm.In this base On plinth, diffusion velocity equation of the gas from solution gas into bubble is derived, establishes three-dimensional two-phase multicomponent dissolved gas drive mathematics Model, and combination finite difference method and implicit pressure explicit saturation method (IMPES) solve to it, it is determined that three-dimensional heavy crude reservoir dissolved gas drive mistake Saturation distribution, dissolved gas oil ratio, oil production and the gas production of reservoir pressure distribution, oil phase and gas phase in journey.Afterwards, with tool The heavy crude reservoir dissolved gas drive experiment for having foam oil phenomenon is foundation, and the uncertain ginseng of model is determined by the method for experimental fit Number.Finally, development effectiveness parameter affecting laws are disclosed by the model after fitting, understand foam oil phenomenon, predict oil field production capacity, Formulate countermeasures of development and improve the recovery factor of heavy oil reservoir with foam oil phenomenon.
The concrete technical scheme of the present invention is as follows：
A kind of heavy crude reservoir dissolved gas drive method for numerical simulation with foam oil phenomenon, comprises the following steps：
Step 1. reads in reset pressure, saturation degree, porosity and permeability according to oil reservoir or experiment rock core physical parameter Data, initialization model；According to simulation precision requirement and computer computation ability, partitioning model grid；According to oil reservoir or reality Rock core porosity distribution is tested, selects density fonction；
Step 2. is according to the balance pressure p of current timee1Calculate the balance pressure p of future timee2：Oil well fixed output quota liquid measure Q During production, according to material balance principle, in the state of the equilibrium, the yield of oil reservoir is equal to the oil reservoir hole caused by reservoir pressure declines The change of gap volume, i.e.,
In formula (I), pe1And pe2The respectively balance pressure of current time and future time, MPa；During initial calculation, pe1For Initial reservoir pressure；CtFor oil reservoir system compressibility, 1/MPa；V is reservoir pore cumulative volume, cm3；Δ t is time step, s；
Because bubble is dispersed in oil phase, the oil gas of foam oil mutually oozes relation not only to be needed to consider gas phase saturation step 3. Influence to oil gas relative permeability, and need to consider influence of the viscous force of viscous crude to oil gas relative permeability；Therefore, originally Invention calculates oil gas relative permeability by below equation：
Wherein：
Sgc=Sgci+βvμo 1/2 (V)
In formula (II)-(V), SgFor gas phase saturation；SgcFor critical gas phase saturation；noFor oil phase Corey indexes；ngFor Gas phase Corey indexes；V is fluid-flow rate, cm/s；μoFor oil phase viscosity, mPas；kroFor oil relative permeability；krg For gas phase relative permeability；krg 0For the endpoint value of gas phase relative permeability；kro 0For the endpoint value of oil relative permeability；krgi For the maximum of the endpoint value of gas phase relative permeability；α and β is coefficient correlation；SgciFor minimum critical gas phase saturation；
For step 4. after reservoir pressure p is less than bubble point pressure, crude oil is in hypersaturated state, is judged by below equation Whether the bubble of crude oil is nucleated：
In formula (VI)-(VII), Δ p is supersaturated pressure, MPa；P is reservoir pressure, MPa；peTo balance pressure, MPa； γ is interface of oil and gas tension force, dyne/cm；rpFor porous media hole mesopore radius, m；
IfThen bubble starts to be nucleated, and foam oil phenomenon produces, and now needs to consider air bubble growth Influence, therefore, to step 5；
IfThen bubble is not yet nucleated, and viscous crude is still flowed with single-phase form in oil reservoir, does not produce bubble Foam oil phenomenon；It therefore, there is no need to calculate the diffusion velocity of air bubble growth and gas from solution gas into bubble, directly carry out Step 7；
Step 5. due to gas concentration on bubble border with being had differences in oil phase, therefore, gas in oil phase can be continuous It is diffused into bubble and causes air bubble growth, the calculation formula of bubble radius is as follows：
In formula (VIII),Changed with time rate for bubble radius；R is bubble radius, m；D is gas in oil phase Diffusion coefficient, m2/s；R is universal gas constant；T is temperature, K；RsFor the dissolved gas oil ratio of foam oil, m3/m3；ReFor balance Dissolved gas oil ratio under state, m3/m3；ρgscFor gas molar density, mol/m3；BoFor oil phase volume coefficient, m3/m3；
Step 6. calculates diffusion velocity q of the gas from solution gas into bubble by below equations→b：
In formula (IX), NjIt is individual for bubbles number；tjFor the growth time of bubble, s；
Step 7. considers diffusion of the gas from solution gas into bubble, establishes viscous crude, dissolving according to conservation of mass principle The D beam element mathematical modeling of gas and bubble composition is as follows：
In formula (X), H is absolute altitude, the vertical direction depth counted by a certain reference plane, m；λoAnd λgIt is that oil phase is gentle respectively The mobility of phase；SoFor oil-phase saturation；qvoAnd qvgRespectively oil production and gas production, cm3/s；φ is porosity；ρoFor crude oil Density, kg/m3；ρgFor natural gas density, kg/m3；BgFor gaseous phase volume coefficient, m3/m3；
The initial pressure of oil reservoir known to step 8. and initial saturation degree, outside pool boundary are closed boundary, and inner boundary is fixed Liquid produces, and calculates the pressure of oil reservoir, the saturation degree of oil phase and gas phase, dissolved gas oil ratio, oil production and gas production；
Step 9. is tested according to the heavy crude reservoir dissolved gas drive based on fill out sand tube or rock core, adjusts uncertain ginseng Number：Density fonction parameter, oil phase Corey indexes noWith gas phase Corey indexes ng, diffusion coefficient D of the gas in oil phase intend Experimental data is closed, reliable model is provided for follow-up actual oil reservoir research.
Based on the model after fitting, disclose density fonction parameter, exhaustion speed, viscosity, interface of oil and gas tension force, The shadow of critical gas saturation, permeability and diffusion coefficient to the heavy crude reservoir dissolved gas drive development process with foam oil phenomenon Ring, predict oil field production capacity, formulate countermeasures of development and improve oil recovery.
According to currently preferred, in the step 1, density fonction uses normal state, Rayleigh and Lai Si Density Distributions Function, suitable density fonction and its parameter are finally determined by experimental fit：
Normal density is distributed：
Rayleigh density is distributed：
This Density Distribution of Lay：
In formula (XI), f (rp) it is density fonction, σ is standard deviation, μ, RmIt is constant with A, I0() is the 0 of amendment Rank Bessel function of the first kind.
According to currently preferred, in the step 2, system compressibility C in public formula (I)tCalculated with below equation：
In formula (XII), CfFor the compressed coefficient of rock matrix in oil reservoir or experiment rock core, 1/MPa.
According to currently preferred, in the step 6, bubbles number is calculated by below equation：
In formula (XIII), δ is the fraction that the hole containing activation bubble accounts for total pore space；VsFor hole average external volume, cm3； rp1For current time tiCorresponding pore radius, m；rp2For subsequent time ti+1Corresponding pore radius, m；
The growth time t of bubblej=ti+1-ti。
According to currently preferred, in the step 7, the D beam element mathematics of simultaneous viscous crude, solution gas and bubble composition Model, obtain below equation：
In formula (XIV), (XV), CGo=-▽ [λo▽(ρogH)]；CGg=-▽ [λg▽(ρggH)]；
CGsg=-▽ [Rsλo▽(ρo gH)]。
According to currently preferred, in the step 8, outside pool boundary is closed boundary, is realized by below equation：
Inner edge defines liquid production, Liquid output Q, cm3/s；
Calculating the pressure of oil reservoir, the saturation degree of oil phase and gas phase, dissolved gas oil ratio, the method for oil production and gas production is： First, finite difference is carried out to two formula (XIV and XV).Due to comprising only mono- unknown number of p in formula (XIV), solve public Formula (XIV) obtains reservoir pressure；Then, solution formula (XV) obtains the dissolved gas oil ratio R of foam oils；Utilize implicit pressure explicit saturation method (IMPES) solve and obtain the saturation degree S of oil phaseo, according to normalization principle So+Sg=1, obtain the saturation degree S of gas phaseg, finally, Oil production and gas production are calculated using below equation：
In formula (XVI), (XVII), Γ is outside pool boundary, and n is the normal direction of outside pool boundary, μgFor gaseous viscosity, mPa·s。
Advantage of the invention is that：
, can be from micro- the invention provides a kind of heavy crude reservoir dissolved gas drive method for numerical simulation with foam oil phenomenon See angle to set out, describe bubble nucleating, growth rhythm during special viscous crude dissolved gas drive, calculate gas from solution gas to gas Diffusion velocity in bubble, it is determined that the saturation degree point of the pressure distribution, oil phase and gas phase during three-dimensional heavy crude reservoir dissolved gas drive Cloth, dissolved gas oil ratio, oil production and gas production.Viscous crude dissolved gas drive was developed so as to preferably simulate foam oil phenomenon The influence of journey, the accuracy of prediction is substantially increased, to disclosing parameter affecting laws, understand foam oil phenomenon, the production of prediction oil field Can, formulation countermeasures of development improves such special recovery factor of heavy oil reservoir tool and is of great significance.
Brief description of the drawings
Fig. 1 is the flow chart of analogy method of the present invention；
Fig. 2 is the mesopore volume distributed median schematic diagram of the embodiment of the present invention 1；
Fig. 3 a are saturation degree distribution maps in fill out sand tube at the end of being calculated in the embodiment of the present invention 1, wherein, viscous crude phase saturation Distribution map；
Fig. 3 b are saturation degree distribution maps in fill out sand tube at the end of being calculated in the embodiment of the present invention 1, wherein, gas phase saturation point Butut；
Fig. 4 is experimental result and digital-to-analogue result of calculation comparison diagram in the embodiment of the present invention 1；
Fig. 5 a are oil reservoir average pressure parameter affecting laws figures in the embodiment of the present invention 1, wherein, density fonction acceptance of the bid Influences of the accurate poor σ to oil reservoir average pressure；
Fig. 5 b are oil reservoir average pressure parameter affecting laws figures in the embodiment of the present invention 1, wherein, γ pairs of interface of oil and gas tension force The influence of oil reservoir average pressure；
Fig. 6 a be in the embodiment of the present invention 2 with foam oil phenomenon viscous crude dissolved gas drive calculate terminate rear reservoir pressure and Oil-phase saturation distribution schematic diagram, wherein, reservoir pressure distribution map；
Fig. 6 b be in the embodiment of the present invention 2 with foam oil phenomenon viscous crude dissolved gas drive calculate terminate rear reservoir pressure and Oil-phase saturation distribution schematic diagram, wherein, oil-phase saturation distribution map；
Fig. 7 is that have the heavy crude reservoir dissolved gas drive of foam oil phenomenon and wells in conventional heavy oil reservoir molten in the embodiment of the present invention 2 Solve gas drive recovery factor calculation comparative result figure.
Embodiment
The present invention is described in detail with reference to embodiment and Figure of description, but not limited to this.
Embodiment 1,
The present embodiment 1 determines that model can not to be fitted the one-dimensional viscous crude dissolved gas drive experimental data with foam oil phenomenon It is that the three-dimensional actual Forecast Oil Reservoir Distribution in embodiment 2 improves reliable model parameter by parameter.Experiment is a length of from fill out sand tube rock core 60cm, cross-sectional area 20cm2, model permeability is 1.25D, and porosity 0.386, the compressed coefficient of rock is 3.2 × 10- 3MPa-1.Experimental temperature is 25 DEG C, and model initial pressure is 4.19MPa, and crude oil bubble point pressure is 3.96MPa, interface of oil and gas tension force γ=30dyne/cm, viscosity of crude, oil volume factor under bubble point pressure, dissolved gas oil ratio be respectively 1100cp, 1.05, 15.57m3/m3.Fill out sand tube left end is closed, right-hand member fixed output quota liquid measure Q=8.3333 × 10-4cm3/ s is produced, and test obtains experimentation In back-up sand pipe pressure, oil production and gas production change.
Fig. 1 is the calculation flow chart of the embodiment of the present invention 1.
A kind of heavy crude reservoir dissolved gas drive method for numerical simulation with foam oil phenomenon, comprises the following steps：
Step 1. reads in reset pressure, saturation degree, porosity and permeability according to oil reservoir or experiment rock core physical parameter Data, initialization model；According to simulation precision requirement and computer computation ability；According to oil reservoir or experiment rock core distribution of pores Feature, select density fonction；
In the step 1, density fonction uses normal state, Rayleigh and Lai Si density fonctions, passes through experimental fit Finally determine suitable density fonction and its parameter：
Normal density is distributed：
Rayleigh density is distributed：
This Density Distribution of Lay：
In formula (XI), f (rp) it is density fonction, σ is standard deviation, μ, RmIt is constant with A, I0() is 0 rank of amendment Bessel function of the first kind.
It is initial according to the actual reset pressure of above-mentioned fill out sand tube, saturation degree, porosity and permeability data in the present embodiment 1 Change model；According to simulation precision requirement and computer computation ability, partitioning model grid is 120 × 1 × 1；According to fill out sand tube rock Heart porosity distribution, using rayleigh density distribution function, as shown in Fig. 2 other relevant parameters are shown in Table 1.
The Parameters in Mathematical Model of table 1
Step 2. is according to the balance pressure p of current timee1Calculate the balance pressure p of future timee2：Oil well with production Q= 8.3333×10-4cm3/ s is produced, and according to material balance principle, in the state of the equilibrium, the yield of oil reservoir is equal to because under reservoir pressure The change of reservoir pore volume caused by drop, i.e.,
In formula (I), pe1And pe2The respectively balance pressure of current time and future time, MPa；During initial calculation, pe1For Initial reservoir pressure；CtFor oil reservoir system compressibility, 1/MPa；V is reservoir pore cumulative volume, cm3；Δ t is time step, s；
In the step 2, system compressibility C in public formula (I)tCalculated with below equation：
In formula (XII), CfFor the compressed coefficient of rock matrix in oil reservoir or experiment rock core, 1/MPa.
In the present embodiment 1, time step is Δ t=50s, initial reservoir pressure pe1=4.19MPa, current time calculate Gained system compressibility is Ct=3.2 × 10-3MPa-1, then balance pressure p during future time t=50se2=4.16MPa；
Because bubble is dispersed in oil phase, the oil gas of foam oil mutually oozes relation not only to be needed to consider gas phase saturation step 3. Influence to oil gas relative permeability, and need to consider influence of the viscous force of viscous crude to oil gas relative permeability；Therefore, originally Invention calculates oil gas relative permeability by below equation：
Wherein：
Sgc=Sgci+βvμo 1/2 (V)
In formula (II)-(V), SgFor gas phase saturation；SgcFor critical gas phase saturation；noFor oil phase Corey indexes；ngFor Gas phase Corey indexes；V is fluid-flow rate, cm/s；μoFor oil phase viscosity, mPas；kroFor oil relative permeability；krg For gas phase relative permeability；krg 0For the endpoint value of gas phase relative permeability；kro 0For the endpoint value of oil relative permeability；krgi For the maximum of the endpoint value of gas phase relative permeability；α and β is coefficient correlation；SgciFor minimum critical gas phase saturation；Due to Fill out sand tube saturated oils, initial oil-phase saturation So=1, initial gas phase saturation Sg=0, the initial relative permeability k of oil phasero= 1, the initial relative permeability of gas phase is krg=0, before bubble nucleating, the saturation degree of oil phase and gas phase keeps constant, therefore, The relative infiltration of oil phase and gas phase also keeps constant；
For step 4. after reservoir pressure p is less than bubble point pressure, crude oil is in hypersaturated state, is judged by below equation Whether the bubble of crude oil is nucleated：
In formula (VI)-(VII), Δ p is supersaturated pressure, MPa；P is reservoir pressure, MPa；peTo balance pressure, MPa； γ is interface of oil and gas tension force, dyne/cm；rpFor porous media hole mesopore radius, m；
IfThen bubble starts to be nucleated, and foam oil phenomenon produces, and now needs to consider air bubble growth Influence, therefore, to step 5；
IfThen bubble is not yet nucleated, and viscous crude is still flowed with single-phase form in oil reservoir, does not produce bubble Foam oil phenomenon；It therefore, there is no need to calculate the diffusion velocity of air bubble growth and gas from solution gas into bubble, directly carry out Step 7；
In the present embodiment 1, interface of oil and gas tension force γ=30dyne/cm, hole maximum radius rpmax=1.0e-7, the time Step, reservoir pressure are equal to balance pressure, Δ p=pe- p=0.Therefore,Bubble is not yet nucleated, in oil reservoir Viscous crude is still flowed with single-phase form, does not produce foam oil phenomenon.It therefore, there is no need to calculate air bubble growth and gas from dissolving Diffusion velocity in from gas to bubble, i.e. qs→bFor 0, step 5 and step 6 are omitted；
Step 5. due to gas concentration on bubble border with being had differences in oil phase, therefore, gas in oil phase can be continuous It is diffused into bubble and causes air bubble growth, the calculation formula of bubble radius is as follows：
In formula (VIII),Changed with time rate for bubble radius；R is bubble radius, m；D is gas in oil phase Diffusion coefficient, m2/s；R is universal gas constant；T is temperature, K；RsFor the dissolved gas oil ratio of foam oil, m3/m3；ReFor balance Dissolved gas oil ratio under state, m3/m3；ρgscFor gas molar density, mol/m3；BoFor oil phase volume coefficient, m3/m3；
Step 6. calculates diffusion velocity q of the gas from solution gas into bubble by below equations→b：
In formula (IX), NjIt is individual for bubbles number；tjFor the growth time of bubble, s；
In the step 6, bubbles number is calculated by below equation：
In formula (XIII), δ is the fraction that the hole containing activation bubble accounts for total pore space；VsFor hole average external volume, cm3； rp1For current time tiCorresponding pore radius, m；rp2For subsequent time ti+1Corresponding pore radius, m；
The growth time t of bubblej=ti+1-ti；
Step 7. considers diffusion of the gas from solution gas into bubble, establishes viscous crude, dissolving according to conservation of mass principle The D beam element mathematical modeling of gas and bubble composition is as follows：
In formula (X), H is absolute altitude, the vertical direction depth counted by a certain reference plane, m；λoAnd λgIt is that oil phase is gentle respectively The mobility of phase；SoFor oil-phase saturation；qvoAnd qvgRespectively oil production and gas production, cm3/s；φ is porosity；ρoFor crude oil Density, kg/m3；ρgFor natural gas density, kg/m3；BgFor gaseous phase volume coefficient, m3/m3；
In the step 7, the D beam element mathematical modeling of simultaneous viscous crude, solution gas and bubble composition, below equation is obtained：
In formula (XIV), (XV), CGo=-▽ [λo▽(ρogH)]；CGg=-▽ [λg▽(ρggH)]；
CGsg=-▽ [Rsλo▽(ρogH)]；
In the present embodiment 1, because fill out sand tube drop test is one-dimensional model, therefore, by above-mentioned D beam element mathematical modeling Abbreviation is following one-dimensional model：
The initial pressure of oil reservoir known to step 8. and initial saturation degree, outside pool boundary are closed boundary, and inner boundary is fixed Liquid produces, and calculates the pressure of oil reservoir, the saturation degree of oil phase and gas phase, dissolved gas oil ratio, oil production and gas production；
In the step 8, outside pool boundary is closed boundary, is realized by below equation：
Inner edge defines liquid production, Liquid output Q, cm3/s；
Calculating the pressure of oil reservoir, the saturation degree of oil phase and gas phase, dissolved gas oil ratio, the method for oil production and gas production is： First, finite difference is carried out to two formula (XIV and XV).Due to comprising only mono- unknown number of p in formula (XIV), solve public Formula (XIV) obtains reservoir pressure；Then, solution formula (XV) obtains the dissolved gas oil ratio R of foam oils；Utilize implicit pressure explicit saturation method (IMPES) solve and obtain the saturation degree S of oil phaseo, according to normalization principle So+Sg=1, obtain the saturation degree S of gas phaseg, finally, Oil production and gas production are calculated using below equation：
In formula (XVI), (XVII), Γ is outside pool boundary, and n is the normal direction of outside pool boundary, μgFor gaseous viscosity, mPa·s；
Future time is set to walk, repeat step 1~8, reservoir pressure before bubble nucleating is calculated under each time step, Oil phase and gas phase saturation, dissolved gas oil ratio, oil production and gas production, q in formula during calculatings→bEqual to 0.
Work as degree of supersaturationWhen, bubble starts to be nucleated, and is calculated by step 5 and step 6 The speed q that bubble radius and gas spread from solution gas into bubbles→b；The time step is calculated by above-mentioned one-dimensional model Reservoir pressure, oil phase and gas phase saturation, dissolved gas oil ratio, oil production and gas production, q in formulas→bNot equal to 0；
Repeat step 1~8, calculate reservoir pressure, oil phase and gas phase saturation (figure under each time step after bubble nucleating 3a and Fig. 3 b), dissolved gas oil ratio, oil production and gas production, q in formulas→bNot equal to 0, until time t walks equal to maximum time tmax, calculating terminates；
Step 9. is tested according to the heavy crude reservoir dissolved gas drive based on fill out sand tube or rock core, adjusts uncertain ginseng Number：Density fonction parameter, oil phase Corey indexes noWith gas phase Corey indexes ng, diffusion coefficient D of the gas in oil phase intend Experimental data is closed, reliable model is provided for follow-up actual oil reservoir research.
In the present embodiment 1, density fonction parameter, oil phase Corey indexes n after adjustmentoWith gas phase Corey indexes ng、 Diffusion coefficient D of the gas in oil phase is shown in Table 2.The experimental result of oil reservoir average pressure and simulation result of calculation pair as shown in Figure 4 Understand that result of calculation is basically identical with experimental result than figure, show the distribution of pores parameter after being adjusted in computation model, oil phase Corey indexes noWith gas phase Corey indexes ng, diffusion coefficient D of the gas in oil phase have higher reliability, to be follow-up actual Oil reservoir research improves reliable model parameter.
The Parameters in Mathematical Model that table 2 is fitted
Based on the model after fitting, disclose density fonction parameter, exhaustion speed, viscosity, interface of oil and gas tension force, Critical gas saturation, permeability and diffusion coefficient are to the heavy crude reservoir dissolved gas drive development process with foam oil phenomenon Influence, predict oil field production capacity, formulate countermeasures of development and improve oil recovery.
The present embodiment 1 have studied density fonction Plays difference σ and interface of oil and gas tension force γ to oil reservoir average pressure Influence.From Fig. 5 a, standard deviation sigma is bigger, maximum pore radius rpmaxBigger, the supersaturated pressure required for bubble nucleating is got over It is small, the easier formation of foam oil phenomenon；From Fig. 5 b, interface of oil and gas tension force γ is smaller, the supersaturation required for bubble nucleating Pressure is also smaller, and bubble nucleating is easier.Therefore, interface of oil and gas tension force and density fonction parameter are to influence bubble nucleating Key factor, can promote the formation of foam oil phenomenon by reducing interface of oil and gas tension force, and then improve with foam oil phenomenon Recovery factor of heavy oil reservoir.
Embodiment 2,
A kind of heavy crude reservoir dissolved gas drive method for numerical simulation with foam oil phenomenon as described in Example 1, its area It is not, reservoir area is 300m × 300m, and reservoir thickness 50m, oil reservoir middle part a bite well is with fixed output quota amount 15m3/ d is produced, its He uses the parameter for being fitted to obtain in embodiment 1 at parameter.Partitioning model grid is 15 × 15 × 5, and other parameters use embodiment 1 Parameter after middle experimental fit, calculation procedure are same as Example 1.
Fig. 6 a are shown in reservoir pressure distribution after simulation calculates, and Fig. 6 b are shown in oil-phase saturation distribution.It can be seen from Fig. 6 a by In the production of producing well, the middle part from reservoir boundary to oil reservoir, the speed that reservoir pressure is gradually reduced and reduced is more and more faster, is in Existing funneling decline.It can be seen from Fig. 6 b from reservoir boundary to oil reservoir middle part, what oil-phase saturation was gradually reduced and reduced Speed is more and more faster.The studies above result meets the heavy crude reservoir dissolved gas drive actual development process with foam oil phenomenon, table The reliability of the bright method for numerical simulation prediction result.
As shown in Figure 7, compared with wells in conventional heavy oil reservoir dissolved gas drive, there is the heavy crude reservoir dissolved gas drive of foam oil phenomenon Recovery ratio improves 3.64%, illustrates that foam oil phenomenon can effectively improve the recovery ratio of heavy crude reservoir.It is it follows that of the invention A kind of heavy crude reservoir dissolved gas drive method for numerical simulation with foam oil phenomenon can effectively simulate foam oil phenomenon, for Heavy crude reservoir dissolved gas drive process of the research with foam oil phenomenon, predicts oil field production capacity, formulates countermeasures of development and improves such spy Different oil recovery tool is of great significance.

Claims (6)

  1. A kind of 1. heavy crude reservoir dissolved gas drive method for numerical simulation with foam oil phenomenon, it is characterised in that the analogy method Comprise the following steps：
    Step 1. reads in reset pressure, saturation degree, porosity and permeability number according to oil reservoir or experiment rock core physical parameter According to initialization model；Partitioning model grid；According to oil reservoir or experiment rock core porosity distribution, density fonction is selected；
    Step 2. is according to the balance pressure p of current timee1Calculate the balance pressure p of future timee2：Oil well fixed output quota liquid measure Q is produced When, according to material balance principle, in the state of the equilibrium, the yield of oil reservoir is equal to the reservoir pore body caused by reservoir pressure declines Long-pending change, i.e.,
    <mrow> <msub> <mi>p</mi> <mrow> <mi>e</mi> <mn>2</mn> </mrow> </msub> <mo>=</mo> <msub> <mi>p</mi> <mrow> <mi>e</mi> <mn>1</mn> </mrow> </msub> <mo>-</mo> <mfrac> <mrow> <mi>Q</mi> <mo>&amp;CenterDot;</mo> <mi>&amp;Delta;</mi> <mi>t</mi> </mrow> <mrow> <msub> <mi>C</mi> <mi>t</mi> </msub> <mi>V</mi> </mrow> </mfrac> <mo>-</mo> <mo>-</mo> <mo>-</mo> <mrow> <mo>(</mo> <mi>I</mi> <mo>)</mo> </mrow> </mrow>
    In formula (I), pe1And pe2The respectively balance pressure of current time and future time, MPa；During initial calculation, pe1To be initial Reservoir pressure；CtFor oil reservoir system compressibility, 1/MPa；V is reservoir pore cumulative volume, cm3；Δ t is time step, s；
    Step 3. calculates oil gas relative permeability by below equation：
    <mrow> <msub> <mi>k</mi> <mrow> <mi>r</mi> <mi>o</mi> </mrow> </msub> <mo>=</mo> <msubsup> <mi>k</mi> <mrow> <mi>r</mi> <mi>o</mi> </mrow> <mn>0</mn> </msubsup> <msup> <mrow> <mo>(</mo> <mfrac> <mrow> <mn>1</mn> <mo>-</mo> <msub> <mi>S</mi> <mi>g</mi> </msub> </mrow> <mrow> <mn>1</mn> <mo>-</mo> <msub> <mi>S</mi> <mrow> <mi>g</mi> <mi>c</mi> </mrow> </msub> </mrow> </mfrac> <mo>)</mo> </mrow> <msub> <mi>n</mi> <mi>o</mi> </msub> </msup> <mo>-</mo> <mo>-</mo> <mo>-</mo> <mrow> <mo>(</mo> <mi>I</mi> <mi>I</mi> <mo>)</mo> </mrow> </mrow>
    <mrow> <msub> <mi>k</mi> <mrow> <mi>r</mi> <mi>g</mi> </mrow> </msub> <mo>=</mo> <msubsup> <mi>k</mi> <mrow> <mi>r</mi> <mi>g</mi> </mrow> <mn>0</mn> </msubsup> <msup> <mrow> <mo>(</mo> <mfrac> <mrow> <msub> <mi>S</mi> <mi>g</mi> </msub> <mo>-</mo> <msub> <mi>S</mi> <mrow> <mi>g</mi> <mi>c</mi> </mrow> </msub> </mrow> <mrow> <mn>1</mn> <mo>-</mo> <msub> <mi>S</mi> <mrow> <mi>g</mi> <mi>c</mi> </mrow> </msub> </mrow> </mfrac> <mo>)</mo> </mrow> <msub> <mi>n</mi> <mi>g</mi> </msub> </msup> <mo>-</mo> <mo>-</mo> <mo>-</mo> <mrow> <mo>(</mo> <mi>I</mi> <mi>I</mi> <mi>I</mi> <mo>)</mo> </mrow> </mrow>
    Wherein：
    <mrow> <msubsup> <mi>k</mi> <mrow> <mi>r</mi> <mi>g</mi> </mrow> <mn>0</mn> </msubsup> <mo>=</mo> <msub> <mi>k</mi> <mrow> <mi>r</mi> <mi>g</mi> <mi>i</mi> </mrow> </msub> <mi>exp</mi> <mrow> <mo>(</mo> <mo>-</mo> <msup> <msub> <mi>&amp;alpha;v&amp;mu;</mi> <mi>o</mi> </msub> <mrow> <mn>1</mn> <mo>/</mo> <mn>2</mn> </mrow> </msup> <mo>)</mo> </mrow> <mo>-</mo> <mo>-</mo> <mo>-</mo> <mrow> <mo>(</mo> <mi>I</mi> <mi>V</mi> <mo>)</mo> </mrow> </mrow>
    Sgc=Sgci+βvμo 1/2 (V)
    In formula (II)-(V), SgFor gas phase saturation；SgcFor critical gas phase saturation；noFor oil phase Corey indexes；ngFor gas phase Corey indexes；V is fluid-flow rate, cm/s；μoFor oil phase viscosity, mPas；kroFor oil relative permeability；krgFor gas Phase relative permeability；krg 0For the endpoint value of gas phase relative permeability；kro 0For the endpoint value of oil relative permeability；krgiFor gas The maximum of the endpoint value of phase relative permeability；α and β is coefficient correlation；SgciFor minimum critical gas phase saturation；
    Step 4. judges whether the bubble of crude oil is nucleated by below equation：
    <mrow> <mi>&amp;Delta;</mi> <mi>p</mi> <mo>=</mo> <msub> <mi>p</mi> <mi>e</mi> </msub> <mo>-</mo> <mi>p</mi> <mo>&amp;GreaterEqual;</mo> <mfrac> <mrow> <mn>2</mn> <mi>&amp;gamma;</mi> </mrow> <msub> <mi>r</mi> <mi>p</mi> </msub> </mfrac> <mo>-</mo> <mo>-</mo> <mo>-</mo> <mrow> <mo>(</mo> <mi>V</mi> <mi>I</mi> <mo>)</mo> </mrow> </mrow>
    <mrow> <mi>&amp;Delta;</mi> <mi>p</mi> <mo>=</mo> <msub> <mi>p</mi> <mi>e</mi> </msub> <mo>-</mo> <mi>p</mi> <mo>&lt;</mo> <mfrac> <mrow> <mn>2</mn> <mi>&amp;gamma;</mi> </mrow> <msub> <mi>r</mi> <mi>p</mi> </msub> </mfrac> <mo>-</mo> <mo>-</mo> <mo>-</mo> <mrow> <mo>(</mo> <mi>V</mi> <mi>I</mi> <mi>I</mi> <mo>)</mo> </mrow> </mrow>
    In formula (VI)-(VII), Δ p is supersaturated pressure, MPa；P is reservoir pressure, MPa；peTo balance pressure, MPa；γ is oil Vapor interface tension force, dyne/cm；rpFor porous media hole mesopore radius, m；
    IfThen bubble starts to be nucleated, and foam oil phenomenon produces, to step 5；
    IfThen bubble is not yet nucleated, and does not produce foam oil phenomenon；Directly carry out step 7；
    The calculation formula of step 5. bubble radius is as follows：
    <mrow> <mfrac> <mrow> <mi>d</mi> <mi>r</mi> </mrow> <mrow> <mi>d</mi> <mi>t</mi> </mrow> </mfrac> <mo>=</mo> <mfrac> <mrow> <mi>D</mi> <mi>R</mi> <mi>T</mi> <mrow> <mo>(</mo> <msub> <mi>R</mi> <mi>s</mi> </msub> <mo>-</mo> <msub> <mi>R</mi> <mi>e</mi> </msub> <mo>)</mo> </mrow> <msub> <mi>&amp;rho;</mi> <mrow> <mi>g</mi> <mi>s</mi> <mi>c</mi> </mrow> </msub> </mrow> <mrow> <msub> <mi>prB</mi> <mi>o</mi> </msub> </mrow> </mfrac> <mo>-</mo> <mo>-</mo> <mo>-</mo> <mrow> <mo>(</mo> <mi>V</mi> <mi>I</mi> <mi>I</mi> <mi>I</mi> <mo>)</mo> </mrow> </mrow>
    In formula (VIII),Changed with time rate for bubble radius；R is bubble radius, m；D is diffusion of the gas in oil phase Coefficient, m2/s；R is universal gas constant；T is temperature, K；RsFor the dissolved gas oil ratio of foam oil, m3/m3；ReFor under poised state Dissolved gas oil ratio, m3/m3；ρgscFor gas molar density, mol/m3；BoFor oil phase volume coefficient, m3/m3；
    Step 6. calculates diffusion velocity q of the gas from solution gas into bubble by below equations→b：
    <mrow> <msub> <mi>q</mi> <mrow> <mi>s</mi> <mo>&amp;RightArrow;</mo> <mi>b</mi> </mrow> </msub> <mo>=</mo> <mfrac> <mrow> <mn>8</mn> <msup> <mi>&amp;pi;RTD</mi> <mn>2</mn> </msup> <msup> <mrow> <mo>(</mo> <msub> <mi>R</mi> <mi>s</mi> </msub> <mo>-</mo> <msub> <mi>R</mi> <mi>e</mi> </msub> <mo>)</mo> </mrow> <mn>2</mn> </msup> <msub> <mi>&amp;rho;</mi> <mrow> <mi>g</mi> <mi>s</mi> <mi>c</mi> </mrow> </msub> </mrow> <mrow> <msubsup> <mi>pB</mi> <mi>o</mi> <mn>2</mn> </msubsup> </mrow> </mfrac> <munder> <mo>&amp;Sigma;</mo> <mi>j</mi> </munder> <msubsup> <mi>N</mi> <mi>j</mi> <mrow> <mn>4</mn> <mo>/</mo> <mn>3</mn> </mrow> </msubsup> <msub> <mi>t</mi> <mi>j</mi> </msub> <mo>-</mo> <mo>-</mo> <mo>-</mo> <mrow> <mo>(</mo> <mi>I</mi> <mi>X</mi> <mo>)</mo> </mrow> </mrow>
    In formula (IX), NjIt is individual for bubbles number；tjFor the growth time of bubble, s；
    The D beam element mathematical modeling that step 7. establishes viscous crude, solution gas and bubble composition is as follows：
    <mrow> <mo>&amp;dtri;</mo> <mo>&amp;CenterDot;</mo> <mo>&amp;lsqb;</mo> <msub> <mi>&amp;lambda;</mi> <mi>o</mi> </msub> <mo>&amp;dtri;</mo> <mrow> <mo>(</mo> <mi>p</mi> <mo>-</mo> <msub> <mi>&amp;rho;</mi> <mi>o</mi> </msub> <mi>g</mi> <mi>H</mi> <mo>)</mo> </mrow> <mo>&amp;rsqb;</mo> <mo>+</mo> <msub> <mi>q</mi> <mrow> <mi>v</mi> <mi>o</mi> </mrow> </msub> <mo>=</mo> <mfrac> <mo>&amp;part;</mo> <mrow> <mo>&amp;part;</mo> <mi>t</mi> </mrow> </mfrac> <mrow> <mo>(</mo> <mfrac> <mrow> <msub> <mi>&amp;phi;S</mi> <mi>o</mi> </msub> </mrow> <msub> <mi>B</mi> <mi>o</mi> </msub> </mfrac> <mo>)</mo> </mrow> </mrow>
    <mrow> <mo>&amp;dtri;</mo> <mo>&amp;CenterDot;</mo> <mo>&amp;lsqb;</mo> <msub> <mi>R</mi> <mi>s</mi> </msub> <msub> <mi>&amp;lambda;</mi> <mi>o</mi> </msub> <mo>&amp;dtri;</mo> <mrow> <mo>(</mo> <mi>p</mi> <mo>-</mo> <msub> <mi>&amp;rho;</mi> <mi>o</mi> </msub> <mi>g</mi> <mi>H</mi> <mo>)</mo> </mrow> <mo>&amp;rsqb;</mo> <mo>-</mo> <msub> <mi>q</mi> <mrow> <mi>s</mi> <mo>&amp;RightArrow;</mo> <mi>b</mi> </mrow> </msub> <mo>+</mo> <msub> <mi>R</mi> <mi>s</mi> </msub> <msub> <mi>q</mi> <mrow> <mi>v</mi> <mi>o</mi> </mrow> </msub> <mo>=</mo> <mfrac> <mo>&amp;part;</mo> <mrow> <mo>&amp;part;</mo> <mi>t</mi> </mrow> </mfrac> <mrow> <mo>(</mo> <mfrac> <mrow> <msub> <mi>&amp;phi;R</mi> <mi>s</mi> </msub> <msub> <mi>S</mi> <mi>o</mi> </msub> </mrow> <msub> <mi>B</mi> <mi>o</mi> </msub> </mfrac> <mo>)</mo> </mrow> </mrow>
    <mrow> <mo>&amp;dtri;</mo> <mo>&amp;CenterDot;</mo> <mo>&amp;lsqb;</mo> <msub> <mi>&amp;lambda;</mi> <mi>g</mi> </msub> <mo>&amp;dtri;</mo> <mrow> <mo>(</mo> <mi>p</mi> <mo>-</mo> <msub> <mi>&amp;rho;</mi> <mi>g</mi> </msub> <mi>g</mi> <mi>H</mi> <mo>)</mo> </mrow> <mo>&amp;rsqb;</mo> <mo>+</mo> <msub> <mi>q</mi> <mrow> <mi>s</mi> <mo>&amp;RightArrow;</mo> <mi>b</mi> </mrow> </msub> <mo>+</mo> <msub> <mi>q</mi> <mrow> <mi>v</mi> <mi>g</mi> </mrow> </msub> <mo>=</mo> <mfrac> <mo>&amp;part;</mo> <mrow> <mo>&amp;part;</mo> <mi>t</mi> </mrow> </mfrac> <mrow> <mo>(</mo> <mfrac> <mrow> <msub> <mi>&amp;phi;S</mi> <mi>g</mi> </msub> </mrow> <msub> <mi>B</mi> <mi>g</mi> </msub> </mfrac> <mo>)</mo> </mrow> <mo>-</mo> <mo>-</mo> <mo>-</mo> <mrow> <mo>(</mo> <mi>X</mi> <mo>)</mo> </mrow> </mrow>
    In formula (X), H is absolute altitude, the vertical direction depth counted by a certain reference plane, m；λoAnd λgIt is oil phase and gas phase respectively Mobility；SoFor oil-phase saturation；qvoAnd qvgRespectively oil production and gas production, cm3/s；φ is porosity；ρoFor oil density, kg/m3；ρgFor natural gas density, kg/m3；BgFor gaseous phase volume coefficient, m3/m3；
    The initial pressure of oil reservoir known to step 8. and initial saturation degree, outside pool boundary are closed boundary, and inner boundary is given birth to determine liquid Production, calculates the pressure of oil reservoir, the saturation degree of oil phase and gas phase, dissolved gas oil ratio, oil production and gas production；
    Step 9. is tested according to the heavy crude reservoir dissolved gas drive based on fill out sand tube or rock core, adjusts uncertain parameter：It is close Spend distribution function parameter, oil phase Corey indexes noWith gas phase Corey indexes ng, diffusion coefficient D fitting of the gas in oil phase it is real Test data.
  2. 2. a kind of heavy crude reservoir dissolved gas drive method for numerical simulation with foam oil phenomenon according to claim 1, its It is characterised by, in the step 1, using normal state, Rayleigh and Lai Si density fonctions, it is suitable finally to be determined by experimental fit Density fonction and its parameter：
    Normal density is distributed：
    Rayleigh density is distributed：
    This Density Distribution of Lay：
    In formula (XI), f (rp) it is density fonction, σ is standard deviation, μ, RmIt is constant with A, I0() is 0 rank first of amendment Class Bessel function.
  3. 3. a kind of heavy crude reservoir dissolved gas drive method for numerical simulation with foam oil phenomenon according to claim 1, its It is characterised by, in the step 2, system compressibility C in public formula (I)tCalculated with below equation：
    <mrow> <msub> <mi>C</mi> <mi>t</mi> </msub> <mo>=</mo> <msub> <mi>S</mi> <mi>o</mi> </msub> <msub> <mrow> <mo>&amp;lsqb;</mo> <mo>-</mo> <mfrac> <mn>1</mn> <msub> <mi>B</mi> <mi>o</mi> </msub> </mfrac> <mfrac> <mrow> <mo>&amp;part;</mo> <msub> <mi>B</mi> <mi>o</mi> </msub> </mrow> <mrow> <mo>&amp;part;</mo> <mi>p</mi> </mrow> </mfrac> <mo>+</mo> <mfrac> <msub> <mi>B</mi> <mi>g</mi> </msub> <msub> <mi>B</mi> <mi>o</mi> </msub> </mfrac> <mfrac> <mrow> <mo>&amp;part;</mo> <msub> <mi>R</mi> <mi>s</mi> </msub> </mrow> <mrow> <mo>&amp;part;</mo> <mi>p</mi> </mrow> </mfrac> <mo>&amp;rsqb;</mo> </mrow> <mi>T</mi> </msub> <mo>-</mo> <mfrac> <msub> <mi>S</mi> <mi>g</mi> </msub> <msub> <mi>B</mi> <mi>g</mi> </msub> </mfrac> <msub> <mrow> <mo>(</mo> <mfrac> <mrow> <mo>&amp;part;</mo> <msub> <mi>B</mi> <mi>g</mi> </msub> </mrow> <mrow> <mo>&amp;part;</mo> <mi>p</mi> </mrow> </mfrac> <mo>)</mo> </mrow> <mi>T</mi> </msub> <mo>+</mo> <msub> <mi>C</mi> <mi>f</mi> </msub> <mo>-</mo> <mo>-</mo> <mo>-</mo> <mrow> <mo>(</mo> <mi>X</mi> <mi>I</mi> <mi>I</mi> <mo>)</mo> </mrow> </mrow>
    In formula (XII), CfFor the compressed coefficient of rock matrix in oil reservoir or experiment rock core, 1/MPa.
  4. 4. a kind of heavy crude reservoir dissolved gas drive method for numerical simulation with foam oil phenomenon according to claim 1, its It is characterised by, in the step 6, bubbles number is calculated by below equation：
    <mrow> <msub> <mi>N</mi> <mi>j</mi> </msub> <mo>=</mo> <mfrac> <mrow> <mi>&amp;delta;</mi> <mi>&amp;phi;</mi> </mrow> <msub> <mi>V</mi> <mi>s</mi> </msub> </mfrac> <mo>=</mo> <mfrac> <mrow> <munderover> <mo>&amp;Integral;</mo> <msub> <mi>r</mi> <mrow> <mi>p</mi> <mn>1</mn> </mrow> </msub> <msub> <mi>r</mi> <mrow> <mi>p</mi> <mn>2</mn> </mrow> </msub> </munderover> <mi>f</mi> <mrow> <mo>(</mo> <msub> <mi>r</mi> <mi>p</mi> </msub> <mo>)</mo> </mrow> <msub> <mi>dr</mi> <mi>p</mi> </msub> <mo>&amp;CenterDot;</mo> <mi>&amp;phi;</mi> </mrow> <msub> <mi>V</mi> <mi>s</mi> </msub> </mfrac> <mo>-</mo> <mo>-</mo> <mo>-</mo> <mrow> <mo>(</mo> <mi>X</mi> <mi>I</mi> <mi>I</mi> <mi>I</mi> <mo>)</mo> </mrow> </mrow>
    In formula (XIII), δ is the fraction that the hole containing activation bubble accounts for total pore space；VsFor hole average external volume, cm3；rp1To work as Preceding moment tiCorresponding pore radius, m；rp2For subsequent time ti+1Corresponding pore radius, m；
    The growth time t of bubblej=ti+1-ti。
  5. 5. a kind of heavy crude reservoir dissolved gas drive method for numerical simulation with foam oil phenomenon according to claim 1, its It is characterised by, in the step 7, the D beam element mathematical modeling of simultaneous viscous crude, solution gas and bubble composition, obtains below equation：
    <mrow> <msub> <mi>B</mi> <mi>g</mi> </msub> <mo>&amp;lsqb;</mo> <mo>&amp;dtri;</mo> <mo>&amp;CenterDot;</mo> <mrow> <mo>(</mo> <msub> <mi>&amp;lambda;</mi> <mi>g</mi> </msub> <mo>&amp;dtri;</mo> <mi>p</mi> <mo>)</mo> </mrow> <mo>+</mo> <msub> <mi>CG</mi> <mi>g</mi> </msub> <mo>+</mo> <msub> <mi>q</mi> <mrow> <mi>s</mi> <mo>&amp;RightArrow;</mo> <mi>b</mi> </mrow> </msub> <mo>+</mo> <msub> <mi>q</mi> <mrow> <mi>v</mi> <mi>g</mi> </mrow> </msub> <mo>&amp;rsqb;</mo> <mo>+</mo> <msub> <mi>B</mi> <mi>o</mi> </msub> <mo>&amp;lsqb;</mo> <mo>&amp;dtri;</mo> <mo>&amp;CenterDot;</mo> <mrow> <mo>(</mo> <msub> <mi>&amp;lambda;</mi> <mi>o</mi> </msub> <mo>&amp;dtri;</mo> <mi>p</mi> <mo>)</mo> </mrow> <mo>+</mo> <msub> <mi>CG</mi> <mi>o</mi> </msub> <mo>+</mo> <msub> <mi>q</mi> <mrow> <mi>v</mi> <mi>o</mi> </mrow> </msub> <mo>&amp;rsqb;</mo> <mo>=</mo> <msub> <mi>&amp;phi;C</mi> <mi>t</mi> </msub> <mfrac> <mrow> <mo>&amp;part;</mo> <mi>p</mi> </mrow> <mrow> <mo>&amp;part;</mo> <mi>t</mi> </mrow> </mfrac> <mo>-</mo> <mo>-</mo> <mo>-</mo> <mrow> <mo>(</mo> <mi>X</mi> <mi>I</mi> <mi>V</mi> <mo>)</mo> </mrow> </mrow>
    <mrow> <mo>&amp;dtri;</mo> <mo>&amp;CenterDot;</mo> <mrow> <mo>(</mo> <msub> <mi>R</mi> <mi>s</mi> </msub> <msub> <mi>&amp;lambda;</mi> <mi>o</mi> </msub> <mo>&amp;dtri;</mo> <mi>p</mi> <mo>)</mo> </mrow> <mo>+</mo> <msub> <mi>CG</mi> <mrow> <mi>s</mi> <mi>g</mi> </mrow> </msub> <mo>-</mo> <msub> <mi>q</mi> <mrow> <mi>s</mi> <mo>&amp;RightArrow;</mo> <mi>b</mi> </mrow> </msub> <mo>-</mo> <msub> <mi>R</mi> <mi>s</mi> </msub> <mo>&amp;lsqb;</mo> <mo>&amp;dtri;</mo> <mo>&amp;CenterDot;</mo> <mrow> <mo>(</mo> <msub> <mi>&amp;lambda;</mi> <mi>o</mi> </msub> <mo>&amp;dtri;</mo> <mi>p</mi> <mo>)</mo> </mrow> <mo>+</mo> <msub> <mi>CG</mi> <mi>o</mi> </msub> <mo>&amp;rsqb;</mo> <mo>=</mo> <mfrac> <mrow> <msub> <mi>&amp;phi;S</mi> <mi>o</mi> </msub> </mrow> <msub> <mi>B</mi> <mi>o</mi> </msub> </mfrac> <mfrac> <mrow> <mo>&amp;part;</mo> <msub> <mi>R</mi> <mi>s</mi> </msub> </mrow> <mrow> <mo>&amp;part;</mo> <mi>t</mi> </mrow> </mfrac> <mo>-</mo> <mo>-</mo> <mo>-</mo> <mrow> <mo>(</mo> <mi>X</mi> <mi>V</mi> <mo>)</mo> </mrow> </mrow>
    In formula (XIV), (XV),
    <mrow> <msub> <mi>CG</mi> <mrow> <mi>s</mi> <mi>g</mi> </mrow> </msub> <mo>=</mo> <mo>-</mo> <mo>&amp;dtri;</mo> <mo>&amp;CenterDot;</mo> <mo>&amp;lsqb;</mo> <msub> <mi>R</mi> <mi>s</mi> </msub> <msub> <mi>&amp;lambda;</mi> <mi>o</mi> </msub> <mo>&amp;dtri;</mo> <mrow> <mo>(</mo> <msub> <mi>&amp;rho;</mi> <mi>o</mi> </msub> <mi>g</mi> <mi>H</mi> <mo>)</mo> </mrow> <mo>&amp;rsqb;</mo> <mo>.</mo> </mrow>
  6. 6. a kind of heavy crude reservoir dissolved gas drive method for numerical simulation with foam oil phenomenon according to claim 1, its It is characterised by, in the step 8, outside pool boundary is closed boundary, is realized by below equation：
    <mrow> <mfrac> <mrow> <mo>&amp;part;</mo> <mi>P</mi> </mrow> <mrow> <mo>&amp;part;</mo> <mi>n</mi> </mrow> </mfrac> <msub> <mo>|</mo> <mi>&amp;Gamma;</mi> </msub> <mo>=</mo> <mn>0</mn> <mo>-</mo> <mo>-</mo> <mo>-</mo> <mrow> <mo>(</mo> <mi>X</mi> <mi>V</mi> <mi>I</mi> <mo>)</mo> </mrow> </mrow>
    Inner edge defines liquid production, Liquid output Q, cm3/s；
    Calculating the pressure of oil reservoir, the saturation degree of oil phase and gas phase, dissolved gas oil ratio, the method for oil production and gas production is：First, Finite difference is carried out to two formula (XIV and XV)；Due to comprising only mono- unknown number of p, solution formula in formula (XIV) (XIV) reservoir pressure is obtained；Then, solution formula (XV) obtains the dissolved gas oil ratio R of foam oils；Asked using implicit pressure explicit saturation method Solution obtains the saturation degree S of oil phaseo, according to normalization principle So+Sg=1, obtain the saturation degree S of gas phaseg, finally, utilize following public affairs Formula calculates oil production and gas production：
    <mrow> <msub> <mi>q</mi> <mrow> <mi>v</mi> <mi>o</mi> </mrow> </msub> <mo>=</mo> <mfrac> <mi>Q</mi> <mrow> <msub> <mi>B</mi> <mi>o</mi> </msub> <mrow> <mo>(</mo> <mn>1</mn> <mo>+</mo> <mfrac> <mrow> <msub> <mi>k</mi> <mrow> <mi>r</mi> <mi>g</mi> </mrow> </msub> <mo>&amp;CenterDot;</mo> <msub> <mi>&amp;mu;</mi> <mi>o</mi> </msub> </mrow> <mrow> <msub> <mi>k</mi> <mrow> <mi>r</mi> <mi>o</mi> </mrow> </msub> <mo>&amp;CenterDot;</mo> <msub> <mi>&amp;mu;</mi> <mi>g</mi> </msub> </mrow> </mfrac> <mo>)</mo> </mrow> </mrow> </mfrac> </mrow>
    <mrow> <msub> <mi>q</mi> <mrow> <mi>v</mi> <mi>g</mi> </mrow> </msub> <mo>=</mo> <mfrac> <mrow> <mi>Q</mi> <mrow> <mo>(</mo> <mfrac> <mrow> <msub> <mi>k</mi> <mrow> <mi>r</mi> <mi>g</mi> </mrow> </msub> <mo>&amp;CenterDot;</mo> <msub> <mi>&amp;mu;</mi> <mi>o</mi> </msub> </mrow> <mrow> <msub> <mi>k</mi> <mrow> <mi>r</mi> <mi>o</mi> </mrow> </msub> <mo>&amp;CenterDot;</mo> <msub> <mi>&amp;mu;</mi> <mi>g</mi> </msub> </mrow> </mfrac> <mo>)</mo> </mrow> </mrow> <mrow> <msub> <mi>B</mi> <mi>g</mi> </msub> <mrow> <mo>(</mo> <mn>1</mn> <mo>+</mo> <mfrac> <mrow> <msub> <mi>k</mi> <mrow> <mi>r</mi> <mi>g</mi> </mrow> </msub> <mo>&amp;CenterDot;</mo> <msub> <mi>&amp;mu;</mi> <mi>o</mi> </msub> </mrow> <mrow> <msub> <mi>k</mi> <mrow> <mi>r</mi> <mi>o</mi> </mrow> </msub> <mo>&amp;CenterDot;</mo> <msub> <mi>&amp;mu;</mi> <mi>g</mi> </msub> </mrow> </mfrac> <mo>)</mo> </mrow> </mrow> </mfrac> <mo>-</mo> <mo>-</mo> <mo>-</mo> <mrow> <mo>(</mo> <mi>X</mi> <mi>V</mi> <mi>I</mi> <mi>I</mi> <mo>)</mo> </mrow> </mrow>
    In formula (XVI), (XVII), Γ is outside pool boundary, and n is the normal direction of outside pool boundary, μgFor gaseous viscosity, mPa s。
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